Lost profit reduction process and system

ABSTRACT

A method and apparatus for detecting a hydrocarbon production trend using a well volume comparison. The method generally includes acquiring well volume data corresponding to a plurality of hydrocarbon-producing wells, comparing the acquired well volume data with target well volume data, assigning a loss production code to at least one of the hydrocarbon-producing wells based on the comparison; and detecting a hydrocarbon production trend utilizing the assigned loss production code.

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention relates generally to methods and apparatuses forevaluating hydrocarbon production. Particularly, various embodiments ofthe present invention provide methods and apparatuses for detecting ahydrocarbon production trend using a well volume comparison.

2. Description of the Related Art

It is often desirable to monitor the production of hydrocarbon-producingwells to determine each well's operating efficiency. For example, bymonitoring a hydrocarbon-production well, one can determine if the wellis in need of maintenance or repair. However, conventional wellmonitoring systems are generally unable to identify trends inhydrocarbon production levels across several wells. Consequently, it isoften difficult to identify trends that correspond to an increase ordecrease in hydrocarbon production.

SUMMARY

In one embodiment of the present invention, there is provided a methodfor detecting a hydrocarbon production trend. The method generallycomprises: (a) acquiring well volume data corresponding to a pluralityof hydrocarbon-producing wells; (b) comparing the acquired well volumedata with target well volume data; (c) assigning a loss production codeto at least one of the hydrocarbon-producing wells based on thecomparison; and (d) detecting a hydrocarbon production trend utilizingthe assigned loss production code.

In another embodiment of the present invention, there is provided acomputer program for detecting a hydrocarbon production trend. Thecomputer program comprises code segments operable to: acquire wellvolume data corresponding to a plurality of hydrocarbon-producing wells;compare the acquired well volume data with target well volume data;assign a loss production code to at least one of thehydrocarbon-producing wells based on the comparison; and detect ahydrocarbon production trend utilizing the assigned loss productioncode.

In still another embodiment of the present invention, there is provideda system for detecting a hydrocarbon production trend. The systemincludes a plurality of measurement devices positioned in a hydrocarbongathering network and a computing device coupled with at least one ofthe measurement devices. The measurement devices are operable to acquirewell volume data corresponding to a plurality of hydrocarbon-producingwells. The computing device is operable to acquire said well volume datafrom at least one of said measurement devices, compare the acquired wellvolume data with target well volume data, assign a loss production codeto at least one of the hydrocarbon-producing wells based on thecomparison, and detect a hydrocarbon production trend utilizing theassigned loss production code.

BRIEF DESCRIPTION OF THE DRAWING FIGURES

Embodiments of the present invention are described in detail below withreference to the attached drawing figures, wherein:

FIG. 1 is a block diagram of a hydrocarbon gathering system;

FIG. 2 is a block diagram of some elements of a computing deviceoperable to be utilized by various embodiments of the present invention;

FIG. 3 is a block diagram showing the computing device of FIG. 2 coupledwith a communications network; and

FIG. 4 is a block diagram showing some of the functions operable to beperformed by various embodiments of the present invention.

DETAILED DESCRIPTION

The following detailed description of various embodiments of theinvention references the accompanying drawings which illustrate specificembodiments in which the invention can be practiced. The embodiments areintended to describe aspects of the invention in sufficient detail toenable those skilled in the art to practice the invention. Otherembodiments can be utilized and changes can be made without departingfrom the scope of the present invention. The following detaileddescription is, therefore, not to be taken in a limiting sense. Thescope of the present invention is defined only by the appended claims,along with the full scope of equivalents to which such claims areentitled.

Various embodiments of the present invention provide a system 10operable to detect a hydrocarbon production trend based on one or morewell volume measurements. Referring initially to FIG. 1, an exemplaryhydrocarbon gathering network 12 is illustrated comprising a pluralityof hydrocarbon-producing wells 14. Each well 14 can be operable toextract hydrocarbon fluids, such as methane, natural gas, petroleum, andthe like, from a subterranean region and provide the extractedhydrocarbon fluids to one or more pipelines or other conduits forstorage and processing.

In some embodiments, as illustrated in FIG. 2, the system 10 can includeone or more measurement devices 16 associated with the hydrocarbongathering network 12 and a computing device 18 operable to acquireinformation measured by one or more of the measurement devices 16. Thecomputing device 18 can be integral with one or more of the measurementdevices 16 and/or the computing device 18 can be remote from one or moreof the measurement devices 16.

Each of the measurement devices 16 can be adapted to acquire well volumedata corresponding to one or more of the wells 14. “Well volume data,”as utilized herein, refers to any data or combination of data thatrepresents the volume of hydrocarbon fluids extracted by one of thewells 14 over a particular time period. In some embodiments, theacquired well volume data can correspond to the volume of hydrocarbonfluids extracted over a twenty-four hour period, a forty-eight hourperiod, a seven day period, a monthly period, a yearly period,combinations thereof, and the like.

In some embodiments, the measurement devices 16 can be operable toacquire well volume data for each of the wells 14 comprising thehydrocarbon gathering network 12. However, in other embodiments, themeasurement devices 16 can acquire well volume data for only a portionof the wells 14. For example, the measurement devices 16 can be adaptedto vary which wells 14 correspond to the acquired well volume data suchthat through periodic measurement well volume data is acquired for allwells 14.

Each of the measurement devices 16 can be associated with one of thewells 14 to acquire hydrocarbon production data, such as well volumedata, therefrom. For example, in some embodiments, each measurementdevice 16 may include an electronic flow meter operable to directly orindirectly acquire well volume data based on sensed measurements. Forinstance, one or more of the measurement devices 16 can directly measurethe volume of produced hydrocarbon fluids to acquire the well volumedata. Additionally or alternatively, one or more of the measurementdevices 16 can be adapted to calculate the well volume data indirectlyfrom hydrocarbon production characteristics.

Each measurement device 16 can include processing and memory elements,discrete from those provided by the computing device 18, to store andprocess data independent of the computing device 18. For example, eachmeasurement device 16 can store well volume data within its memory forperiodic retrieval by the computing device 18 and/or process acquireddata to calculate the well volume data without direct measurement ofproduced hydrocarbon fluid volumes.

In some embodiments, one or more of the measurement devices 16 can beremote from the wells 14 and associated with other portions of thehydrocarbon gathering network 12, such as with pipelines, storage tanks,and the like. Thus, the measurement devices 16 can acquire well volumedata from the other portions of the hydrocarbon gathering network 12without being associated with one or more of the wells 14. Additionallyor alternatively, one or more of the measurement devices 16 can utilizethe devices, systems, and methods disclosed in U.S. Pat. No. 6,978,210,which is incorporated herein by reference, to acquire well volume data.

One or more of the measurement devices 16 can be adapted to communicatewith other measurement devices 16 utilizing wireless and/or wiredcommunication methods. Thus, various measurement devices 16 can sharewell volume data and other measured and acquired information tofacilitate the communication of information to the computing device 18or other components of the system 10.

The computing device 18 can include any element or combination ofelements operable to process information provided by one or more of themeasurement devices 16 to detect a hydrocarbon production trend. In someembodiments, as illustrated in FIG. 2, the computing device 18 can beassociated with a memory 20, a display 22, and/or a communicationselement 24. The various elements of the computing device 18 can bedisposed within a single housing or distributed between a plurality ofdiscrete housings in any combination. The elements of the computingdevice 18 can be coupled together in any configuration utilizing wiredand/or wireless connections.

The computing device 18 can include various analog and digitalcomponents operable to perform the various functions discussed herein.In some embodiments, the computing device 18 can include amicroprocessor, a microcontroller, a programmable logic device, anapplication specific integrated circuit, digital and analog logicdevices, computing elements such as personal computers, servers,computing networks, portable computing devices, combinations thereof,and the like. Thus, the computing device 18 can comprise a plurality ofcomputing elements in some embodiments.

The memory 20 can be associated with the computing device 18 and includememories of any form or configuration for storing computer programs andinformation, as is discussed in more detail below. Thus, the memory 20can comprise a computer-readable medium. In the context of thisapplication, a “computer-readable medium” can be any element orcombination of elements that can contain, store, communicate, propagateor transport at least a portion of a computer program for use by or inconnection with one or more computing devices such as the computingdevice 18.

The computer-readable medium can be, for example, but not limited to, anelectronic, magnetic, optical, electromagnetic, infrared, orsemi-conductor system, apparatus, device, or propagation medium operablefor use by the computing device 18 or other devices. More specific,although not inclusive, examples of the computer-readable medium caninclude the following: an electrical connection having one or morewires, a portable computer diskette, a random access memory (RAM), aread-only memory (ROM), an erasable, programmable, read-only memory(EPROM or flash memory), an optical fiber, a portable compact disc (CD),a digital video disc (DVD), and an electrical signal representing one ormore portions of a computer program. The computer-readable medium couldeven be paper or another suitable medium upon which a program isprinted, as the program an be electronically captured, via for instance,optical scanning of the paper or other medium, then compiled,interpreted, or otherwise processed in a suitable manner, if necessary,and then stored in a computer memory.

The display 22 can be also be associated with the computing device 18and adapted to display information provided by the computing device 18,such as detected hydrocarbon production trends, to one or more users.The display 22 can include various human-readable display elements, suchas cathode-ray tube monitors, liquid crystal displays, a plasma display,a surface-conduction electron-emitter display, a light-emitting diodedisplay, combinations thereof, and the like.

As shown in FIGS. 2-3, the computing device 18 can utilize thecommunications element 24 to access a communications network 26 such asan intranet, peer-to-peer network, and/or the internet to exchangeinformation with other devices associated with and/or connected to thecommunications network 26. The computing device 18 can be operable toaccess the communications network 26 utilizing wired and/or wirelessconnections. Additionally or alternatively, the computing device 18 canutilize the communications element 24 to directly access other devices,systems, and elements, such as the wells 14 and/or measurement devices16, through wired or wireless connections without relying on thecommunications network 26. Thus, in some embodiments, the computingdevice 18 can be positioned remotely from wells 14, hydrocarbongathering network 12, and/or measurement devices 16. Alternatively, thecomputing device 18 can be integrated with one or more of themeasurement devices 16 for use with a common housing and components.

Various functions that can be performed by the system 10 are illustratedin FIG. 4. For example, in some embodiments the system 10 can: acquirewell volume data, referenced at step 100; compare acquired well volumedata with target well volume data, referenced at step 102; assign one ormore loss production codes based on the comparison, referenced at step104; detect a hydrocarbon production trend, referenced at step 106; andadjust a hydrocarbon production process, referenced at step 108.

Some of the steps illustrated in FIG. 4 can represent one or more codesegments comprising at least a portion of a computer program executed bythe computing device 18. Steps 100-108 can be performed in any order andare not limited to the specific order described herein. Steps 100-108can be performed simultaneously or concurrently such that theillustrated steps are not necessarily sequential. Further, steps 100-108are not each necessarily performed by all embodiments of the presentinvention.

In step 100, well volume data corresponding to one or more of the wells14 is acquired. In some embodiments, well volume data is acquired foreach of the wells 14 comprising the hydrocarbon gathering network 12.However, as discussed above, well volume data can be acquired for anystatic or dynamic combination of the wells 14. The well volume data canbe acquired utilizing one or more of the measurement devices 16 asdiscussed above. For example, each measurement device 16 can measurewell volume directly, compute well volume based on acquired information,and/or acquire well volume from other devices or systems.

The computing device 18 can acquire the well volume data from one ormore of the measurement devices 16. For example, in embodiments wherethe computing device 18 is remote from the measurement devices 16, thecomputing device 18 can access one or more of the measurement devices 16utilizing the communications element 24. The computing device 18 canalso communicate with one or more of the measurement devices 16indirectly, such as where an intermediate system stores data provided bythe measurement devices. For example, in some embodiments as shown inFIG. 3, a database 28 can be adapted to communicate with both thecomputing device 18 and measurement devices 16 to store well volume datafor acquisition by the computing device 18. The computing device 18 canalso acquire the well volume data through a user input, such as where auser inputs information corresponding to well volume data to thecomputing device 18 utilizing an input device such as a keyboard and/ormouse.

The computing device 18 can be operable to directly acquire well volumedata from other devices such as the database 28 and/or measurementdevices 16. Additionally or alternatively, the computing device 18 canacquire data and information other than well volume data from varioussources such as the measurement devices 16, database 28, user inputs,combinations thereof, and the like, and calculate and/or estimate thewell volume data utilizing the acquired information. Thus, the computingdevice 18 can acquire the well volume data by processing information andneed not directly acquire the well volume data from the measurementdevices 16.

The computing device 18 can store the acquired well volume data withinthe memory 20 and/or database 28 for later access and retrieval. Thecomputing device 18 can also sort and/or categorize acquired well volumedata by corresponding well 14 and measurement device 16, date ofretrieval, frequency of retrieval, combinations thereof, and the like.

In step 102, the well volume data acquired in step 100 is compared totarget well volume data. “Target well volume data,” as utilized herein,refers to any data or combination of data that represents a targetvolume of hydrocarbon fluids extracted by one of the wells 14 over aparticular time period. In some embodiments, acquired well volume datafor each well 14 can be compared to target well volume data for eachwell 14 to identify any variance between the volumes. Additionally oralternatively, acquired well volume data for any groups or combinationsof the wells 14 can be compared to target well volume data for anygroups or combinations of the wells 14.

The target well volume data can be a predetermined value stored by thecomputing device 18, memory 20, database 28, and/or other portions ofthe system 10. Thus, the value of the target well volume data for eachwell 14 can be defined by the user and/or the computing device 18 priorto the comparison of step 102 to correspond to a desired, expected,and/or previous well volume. For example, the user can select the valueof the target well volume data to correspond to an expected productionamount derived from previous well performance, geophysical analysis,statistical analysis, combinations thereof, and the like.

In some embodiments the target well volume data can be dynamicallygenerated by the computing device 18 in response to various user inputs,acquired well volume data, system 10 information and configuration,combinations thereof, and the like. For example, the computing device 18can dynamically calculate the target well volume data in step 102 basedon present conditions of the hydrocarbon gathering network 12 such thatit is not necessary to utilize predetermined values.

In various embodiments, the computing device 18 is operable to compareacquired well volume data and target well volume data. However, in someembodiments, other portions of the system 10, such as one or more of themeasurement devices 16, can perform the comparison of step 102. Theresults of the comparison, such as if the acquired and target wellvolumes differ and/or the extent to which the well volumes differ, canbe stored within the memory 20 and/or database 28 for later access andretrieval.

Further, in some embodiments, the acquired well volume data and targetwell volume data for one or more of the wells 14 can be compared todetermine if the acquired well volume data varies from the target wellvolume data by more than a tolerance volume. If the acquired well volumedata varies from the target well volume data by more than the tolerancevolume, the computing device 18 can flag or otherwise identify theparticular well 14 to which the acquired well volume data correspondsand store an indication of the flagging or identification within thememory 20 and/or database 28.

The tolerance volume can be a predefined volume generated by the user orthe computing device 18 and stored by the computing device 18, memory20, and/or database 28. For example, the user can select the tolerancevolume to enable substantially underperforming wells to be identified.The value of the tolerance volume can itself be a volume and/or apercent of the target well volume data. For example, if the acquiredwell volume data varies from the target well volume data by more thanten percent, the computing device 18 can flag the well 14 correspondingto the acquired well volume data. Further, the tolerance volume can bethe same for all wells 14 or groups of wells 14 and/or be individuallyselected for each well 14 for which well volume data is acquired.

In step 104, a loss production code can be assigned to at least one ofthe wells 14 based on the comparison performed in step 102. The lossproduction code can indicate the performance of the wells 14, such asthe extent to which the acquired well volume data satisfies the targetwell volume data for each well 14. In some embodiments, the lossproduction code is assigned to one of the wells 14 only if thecomparison of step 102 indicates that the acquired well volume datacorresponding to the particular well 14 varies from the target wellvolume data by more than the tolerance volume discussed above. Thus, forexample, at least one loss production code can be assigned to each well14 flagged by the computing device 18 in step 104.

In some embodiments, the computing device 18 and/or the user of thecomputing device 18 can ascertain the cause of the variance between theacquired well volume data and target well volume data and select one ormore loss production codes that correspond to the cause of the variance.Various exemplary production codes are provided below in Table 1.

TABLE 1 4-Commercial 1-Wells 2-Facilities 3-Export Losses 5-Other 1.12.1 3.1 4.1 5.1 Well Integrity Turbo- 1^(st) Party Commercial Fuel &Machinery Operated Losses Flare 1.2 2.2 3.2 5.2 Artificial Lift OtherRotating Third- Extreme or Wellbore Equipment Party ConditionsHydraulics Operated 1.3 2.3 Simultaneous Process Upsets Operations 1.42.4 Downhole Plant Maintenance or Turnaround Optimization 1.5 2.5Regulatory, Facility Compliance, or Maintenance or SurveillanceModification 1.6 2.6 Downhole Pipeline Impairment Integrity 2.7Gathering System Flow Assurance & Hydraulics 2.8 Power &Fuel 2.9Instrumentation and Control 2.10 Work Process &Human Performance 2.11Facility Capacity 2.12 3rd Party

Thus, if the comparison in step 102 indicates that acquired well volumedata corresponding to a particular well 14 varies from the target wellvolume data for the particular well 14 by more than the tolerancevolume, the computing device 18 and/or user can select one or more ofthe loss production codes to assign to the particular well 14. Forexample, the user can identify the cause of a variance from the targetvolume data as extreme weather (code 6.1) and a turbo-machinerymalfunction (code 2.1). Such production codes can be assigned to eachwell 14 flagged by the computing device 18 in step 102, to all wells 14,and/or only a selected portion of the wells 14.

In some embodiments, the user can manually investigate or otherwiseidentify the cause of the variance and assign one or more correspondingloss production codes accordingly. For example, the computing device 18may visually or audibly prompt the user to enter one or more of the lossproduction codes based on the comparison. Additionally or alternatively,the computing device 18 can automatically assign one or more lossproduction codes based on information available from the user, thememory 20, the database 28, the hydrocarbon gathering network 12,combinations thereof, and the like. For example, the computing device 18can be configured to identify various well and equipment configurationsautomatically and assign corresponding loss production codes to wells 14based on the comparison of step 104 without any input by the user.However, in some embodiments the user and/or computing device 18 may belimited to assigning a single loss production code for each well volumecomparison to facilitate the trend analysis discussed below.

As should be appreciated, embodiments of the present invention canemploy any loss production codes for assignment to the wells 14 as thecodes listed in Table 1 are merely exemplary. In various embodiments,the number of loss production codes is sufficient to enable one or morehydrocarbon production trends to be easily identified in step 106. Thus,in some embodiments, it may be desirable to maximize the number ofassignable loss production codes. However, any number of loss productioncodes and type of loss production codes can be utilized by embodimentsof the present invention.

The assigned loss production codes and an indication of the each code'scorresponding well 14 can be stored by the computing device 18 withinthe memory 20 and/or database 28 for later access and retrieval.Additionally or alternatively, the assigned loss production codes andcorresponding well indications can be provided to the communicationsnetwork 26 for access by other devices and systems.

In step 106, a hydrocarbon production trend is detected utilizing one ormore of the loss production codes assigned in step 104. For example, thecomputing device 18 and/or the user can utilize the assigned lossproduction codes to identify one or more hydrocarbon production trends.For example, based upon assigned loss production codes, the user and/orthe computing device 18 could detect that a decrease in hydrocarbonproduction is associated with the use of a certain pump that fails underhigh temperatures. Similarly, the computing device 18 and/or user coulddetect that an increase in hydrocarbon production is associated with aparticular maintenance schedule, facility, operator, and the like. Assuch, the hydrocarbon production trend may be detected utilizing anycombination of the loss production codes assigned in step 104.

Thus, through the correlation of assigned loss production codes andincreased or decreased hydrocarbon production, embodiments of thepresent invention enable one or more hydrocarbon production trends to beeasily identified even when the hydrocarbon gathering network 12includes a significant number of wells 14. Information associated withthe detected hydrocarbon production trend can be presented on thedisplay 22 to enable understanding by the user and/or stored within thememory 20 and/or database 28 for later access and retrieval.

In some embodiments, steps 100-106 can be repeated such that thedetected hydrocarbon production trend represents a hydrocarbonproduction trend over a period of time. For example, steps 100-104 canbe performed on a daily or weekly basis, such as where the acquired wellvolume data corresponds to a daily production volume, the target wellvolume data corresponds to a target daily production, and the lossproduction codes are assigned on a daily or weekly basis. The detectedhydrocarbon production trend can thus correspond to daily, weekly,bi-weekly, monthly, bimonthly, semi-annual, and/or annual productiontrends. Similarly, a plurality of hydrocarbon production trends can bedetected each corresponding to varying periods of time.

In step 108, a hydrocarbon production process can be adjusted based uponthe hydrocarbon production trend detected in step 106. For example, ifthe detected hydrocarbon production trend indicates that a particulartype of equipment is prone to failure, the user can replace thefailure-prone equipment to increase hydrocarbon production. Similarly,maintenance schedules and the like can be adjusted based on one or moredetected hydrocarbon production trends. The user may provide thecomputing device 18 an indication of the adjustment to enable thecomputing device 18 to utilize the indication to facilitate in thedetection of hydrocarbon production trends.

Detected hydrocarbon production trends may also be evaluated on aperiodic basis, such as monthly, quarterly, yearly, and the like, toallow the user to adjust hydrocarbon production processes only atspecific intervals. Thus, the hydrocarbon production process may beevaluated at intervals different than those represented by the detectedhydrocarbon production trend. As should be appreciated, hydrocarbonproduction processes can be adjusted in any manner based upon thedetected hydrocarbon production trends and are not limited to theexamples provided above.

Embodiments of the present invention thus enable hydrocarbon productiontrends to be easily and rapidly identified in steps 100-106 andappropriate corrections to be implemented in step 108 to reduce downtimeand increase production and well optimization.

As used herein, the terms “a,” “an,” “the,” and “said” means one ormore.

As used herein, the term “and/or,” when used in a list of two or moreitems, means that any one of the listed items can be employed by itself,or any combination of two or more of the listed items can be employed.For example, if a composition is described as containing components A,B, and/or C, the composition can contain A alone; B alone; C alone; Aand B in combination; A and C in combination; B and C in combination; orA, B, and C in combination.

As used herein, the terms “comprising,” “comprises,” and “comprise” areopen-ended transition terms used to transition from a subject recitedbefore the term to one or elements recited after the term, where theelement or elements listed after the transition term are not necessarilythe only elements that make up of the subject.

As used herein, the terms “containing,” “contains,” and “contain” havethe same open-ended meaning as “comprising,” “comprises,” and“comprise,” provided below.

As used herein, the terms “having,” “has,” and “have” have the sameopen-ended meaning as “comprising,” “comprises,” and “comprise,”provided above

As used herein, the terms “including,” “includes,” and “include” havethe same open-ended meaning as “comprising,” “comprises,” and“comprise,” provided above.

As used herein, the term “computer-readable medium” means any element orcombination of elements that can contain, store, communicate, propagateor transport at least a portion of a computer program for use by or inconnection with one or more computing devices.

As used herein, the term “well volume data,” means any data orcombination of data that represents the volume of hydrocarbon fluidsextracted by one of the wells 14 over a particular time period.

As used herein, the term “target well volume data,” means any data orcombination of data that represents a target volume of hydrocarbonfluids extracted by one of the wells 14 over a particular time period.

The preferred forms of the invention described above are to be used asillustration only, and should not be used in a limiting sense tointerpret the scope of the present invention. Modifications to theexemplary embodiments, set forth above, could be readily made by thoseskilled in the art without departing from the spirit of the presentinvention.

The inventors hereby state their intent to rely on the Doctrine ofEquivalents to determine and assess the reasonably fair scope of thepresent invention as it pertains to any apparatus not materiallydeparting from but outside the literal scope of the invention as setforth in the following claims.

1. A method for detecting a hydrocarbon production trend, said methodcomprising: (a) accessing loss production codes assigned to a pluralityof hydrocarbon-producing wells; and (b) detecting a hydrocarbonproduction trend utilizing said assigned loss production codes.
 2. Themethod of claim 1, further including before (a)— (c) assigning said lossproduction codes to said plurality of hydrocarbon-producing wells basedon a comparison of acquired and target well volume data.
 3. The methodof claim 2, wherein said well volume data comparison is performed by acomputing device and said assigned loss production codes are inputted bya user to said computing device.
 4. The method of claim 2, wherein (c)includes assigning one of said loss production codes to a first of saidhydrocarbon-producing wells only if said comparison indicates that saidacquired well volume data for said first hydrocarbon-producing wellvaries from said target well volume data for said firsthydrocarbon-producing well by more than a tolerance volume.
 5. Themethod of claim 4, wherein at least one of said loss production codesare assigned to each hydrocarbon-producing well corresponding toacquired well volume data that varies from said target well volume databy more than said tolerance volume.
 6. The method of claim 2, furtherincluding before (a)— (d) acquiring well volume data corresponding tosaid plurality of hydrocarbon-producing wells.
 7. The method of claim 6,wherein said user acquires said well volume data by instructing saidcomputing device to access a plurality of measurement devices positionedin a hydrocarbon gathering network.
 8. The method of claim 1, furthercomprising adjusting a hydrocarbon production process based on saiddetected hydrocarbon production trend.
 9. The method of claim 1, furthercomprising repeating (a) and (b) such that said detected hydrocarbonproduction trend represents a hydrocarbon production trend over a periodof time.
 10. A method for detecting a hydrocarbon production trend, saidmethod comprising: (a) acquiring well volume data corresponding to aplurality of hydrocarbon-producing wells; (b) comparing said acquiredwell volume data with target well volume data; (c) assigning a lossproduction code to at least one of said hydrocarbon-producing wellsbased on said comparison; and (d) detecting a hydrocarbon productiontrend utilizing said assigned loss production code.
 11. The method ofclaim 10, further comprising adjusting a hydrocarbon production processbased on said detected hydrocarbon production trend.
 12. The method ofclaim 10, further comprising indicating said detected hydrocarbonproduction trend on a human-readable display.
 13. The method of claim10, wherein (a) includes acquiring said well volume data from aplurality of measurement devices positioned in a hydrocarbon gatheringnetwork.
 14. The method of claim 10, wherein (a) includes acquiring saidwell volume data from a computer-readable memory.
 15. The method ofclaim 10, wherein (c) includes assigning said loss production code to atleast one of said hydrocarbon-producing wells only if said comparison of(b) indicates that said acquired well volume data varies from saidtarget well volume data by more than a tolerance volume.
 16. The methodof claim 15, wherein said tolerance volume is predetermined.
 17. Themethod of claim 15, wherein at least one of a plurality of lossproduction codes are assigned to each hydrocarbon-producing wellcorresponding to acquired well volume data that varies from said targetwell volume data by more than said tolerance volume.
 18. The method ofclaim 10, further comprising repeating (a) through (c) such that thedetected hydrocarbon production trend represents a hydrocarbonproduction trend over a period of time.
 19. A system for detecting ahydrocarbon production trend, said system comprising: a plurality ofmeasurement devices positioned in a hydrocarbon gathering network, saidmeasurement devices operable to acquire well volume data correspondingto a plurality of hydrocarbon-producing wells; and a computing devicecoupled with at least one of said measurement devices, said computingdevice operable to— acquire said well volume data from at least one ofsaid measurement devices, compare said acquired well volume data foreach of said hydrocarbon-producing wells with target well volume datafor each of said hydrocarbon-producing wells, provide an indication ofsaid comparisons to a user, and receive a loss production code from saiduser in response to at least one of said comparisons and assign saidreceived loss production code to at least one of saidhydrocarbon-producing wells.
 20. The system of claim 19, wherein saidcomputing device is operable to access at least one of said measurementdevices through a communications network.
 21. The system of claim 19,further comprising a human-readable display coupled with said computingdevice and operable to visually present said indication of saidcomparisons.
 22. The system of claim 19, further comprising acomputer-readable memory coupled with said computing device and operableto store data corresponding to assigned loss production codes.
 23. Thesystem of claim 19, wherein said computing device is further operable toprompt said user for said loss production code for a first of saidhydrocarbon-producing wells only if said comparison indicates that saidacquired well volume data for said first hydrocarbon-producing wellvaries from said target well volume data for said firsthydrocarbon-producing well by more than a tolerance volume.
 24. Thesystem of claim 23, wherein said tolerance volume is a predeterminedvolume stored in a computer-readable memory.
 25. The system of claim 23,wherein said computing device is further operable to prompt said userfor said loss production code for each hydrocarbon-producing well thatcorresponds to acquired well volume data that varies from target wellvolume data by more than said tolerance volume.